US9476294B2 - Device and method for discrete distributed optical fiber pressure sensing - Google Patents
Device and method for discrete distributed optical fiber pressure sensing Download PDFInfo
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- US9476294B2 US9476294B2 US12/956,777 US95677710A US9476294B2 US 9476294 B2 US9476294 B2 US 9476294B2 US 95677710 A US95677710 A US 95677710A US 9476294 B2 US9476294 B2 US 9476294B2
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Images
Classifications
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01D—MEASURING NOT SPECIALLY ADAPTED FOR A SPECIFIC VARIABLE; ARRANGEMENTS FOR MEASURING TWO OR MORE VARIABLES NOT COVERED IN A SINGLE OTHER SUBCLASS; TARIFF METERING APPARATUS; MEASURING OR TESTING NOT OTHERWISE PROVIDED FOR
- G01D5/00—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable
- G01D5/26—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable characterised by optical transfer means, i.e. using infrared, visible, or ultraviolet light
- G01D5/32—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable characterised by optical transfer means, i.e. using infrared, visible, or ultraviolet light with attenuation or whole or partial obturation of beams of light
- G01D5/34—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable characterised by optical transfer means, i.e. using infrared, visible, or ultraviolet light with attenuation or whole or partial obturation of beams of light the beams of light being detected by photocells
- G01D5/353—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable characterised by optical transfer means, i.e. using infrared, visible, or ultraviolet light with attenuation or whole or partial obturation of beams of light the beams of light being detected by photocells influencing the transmission properties of an optical fibre
- G01D5/35338—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable characterised by optical transfer means, i.e. using infrared, visible, or ultraviolet light with attenuation or whole or partial obturation of beams of light the beams of light being detected by photocells influencing the transmission properties of an optical fibre using other arrangements than interferometer arrangements
- G01D5/35341—Sensor working in transmission
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
-
- E21B47/123—
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
- E21B47/13—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. radio frequency
- E21B47/135—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. radio frequency using light waves, e.g. infrared or ultraviolet waves
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01D—MEASURING NOT SPECIALLY ADAPTED FOR A SPECIFIC VARIABLE; ARRANGEMENTS FOR MEASURING TWO OR MORE VARIABLES NOT COVERED IN A SINGLE OTHER SUBCLASS; TARIFF METERING APPARATUS; MEASURING OR TESTING NOT OTHERWISE PROVIDED FOR
- G01D5/00—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable
- G01D5/26—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable characterised by optical transfer means, i.e. using infrared, visible, or ultraviolet light
- G01D5/32—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable characterised by optical transfer means, i.e. using infrared, visible, or ultraviolet light with attenuation or whole or partial obturation of beams of light
- G01D5/34—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable characterised by optical transfer means, i.e. using infrared, visible, or ultraviolet light with attenuation or whole or partial obturation of beams of light the beams of light being detected by photocells
- G01D5/353—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable characterised by optical transfer means, i.e. using infrared, visible, or ultraviolet light with attenuation or whole or partial obturation of beams of light the beams of light being detected by photocells influencing the transmission properties of an optical fibre
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01D—MEASURING NOT SPECIALLY ADAPTED FOR A SPECIFIC VARIABLE; ARRANGEMENTS FOR MEASURING TWO OR MORE VARIABLES NOT COVERED IN A SINGLE OTHER SUBCLASS; TARIFF METERING APPARATUS; MEASURING OR TESTING NOT OTHERWISE PROVIDED FOR
- G01D5/00—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable
- G01D5/26—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable characterised by optical transfer means, i.e. using infrared, visible, or ultraviolet light
- G01D5/32—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable characterised by optical transfer means, i.e. using infrared, visible, or ultraviolet light with attenuation or whole or partial obturation of beams of light
- G01D5/34—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable characterised by optical transfer means, i.e. using infrared, visible, or ultraviolet light with attenuation or whole or partial obturation of beams of light the beams of light being detected by photocells
- G01D5/353—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable characterised by optical transfer means, i.e. using infrared, visible, or ultraviolet light with attenuation or whole or partial obturation of beams of light the beams of light being detected by photocells influencing the transmission properties of an optical fibre
- G01D5/35338—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable characterised by optical transfer means, i.e. using infrared, visible, or ultraviolet light with attenuation or whole or partial obturation of beams of light the beams of light being detected by photocells influencing the transmission properties of an optical fibre using other arrangements than interferometer arrangements
- G01D5/35354—Sensor working in reflection
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01L—MEASURING FORCE, STRESS, TORQUE, WORK, MECHANICAL POWER, MECHANICAL EFFICIENCY, OR FLUID PRESSURE
- G01L1/00—Measuring force or stress, in general
- G01L1/24—Measuring force or stress, in general by measuring variations of optical properties of material when it is stressed, e.g. by photoelastic stress analysis using infrared, visible light, ultraviolet
- G01L1/242—Measuring force or stress, in general by measuring variations of optical properties of material when it is stressed, e.g. by photoelastic stress analysis using infrared, visible light, ultraviolet the material being an optical fibre
- G01L1/243—Measuring force or stress, in general by measuring variations of optical properties of material when it is stressed, e.g. by photoelastic stress analysis using infrared, visible light, ultraviolet the material being an optical fibre using means for applying force perpendicular to the fibre axis
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01L—MEASURING FORCE, STRESS, TORQUE, WORK, MECHANICAL POWER, MECHANICAL EFFICIENCY, OR FLUID PRESSURE
- G01L11/00—Measuring steady or quasi-steady pressure of a fluid or a fluent solid material by means not provided for in group G01L7/00 or G01L9/00
- G01L11/02—Measuring steady or quasi-steady pressure of a fluid or a fluent solid material by means not provided for in group G01L7/00 or G01L9/00 by optical means
- G01L11/025—Measuring steady or quasi-steady pressure of a fluid or a fluent solid material by means not provided for in group G01L7/00 or G01L9/00 by optical means using a pressure-sensitive optical fibre
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01L—MEASURING FORCE, STRESS, TORQUE, WORK, MECHANICAL POWER, MECHANICAL EFFICIENCY, OR FLUID PRESSURE
- G01L19/00—Details of, or accessories for, apparatus for measuring steady or quasi-steady pressure of a fluent medium insofar as such details or accessories are not special to particular types of pressure gauges
- G01L19/0092—Pressure sensor associated with other sensors, e.g. for measuring acceleration or temperature
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V8/00—Prospecting or detecting by optical means
- G01V8/10—Detecting, e.g. by using light barriers
- G01V8/12—Detecting, e.g. by using light barriers using one transmitter and one receiver
- G01V8/16—Detecting, e.g. by using light barriers using one transmitter and one receiver using optical fibres
Definitions
- Optical fiber sensors may be used to monitor many different parameters on structures or in selected environments.
- optical fiber sensors include Fiber Bragg Grating (FBG) sensors that may be utilized to detect strain in an optical fiber.
- FBG Fiber Bragg Grating
- a knowledge of pressure and temperature within a reservoir is important to ensure efficient well and reservoir management.
- an accurate measure of the forces and pressures in the downhole environment is important to facilitate downhole operations as well as protect the integrity of downhole components. Due to the extreme conditions in downhole environments, designing devices for measuring forces, pressures, temperatures, and other conditions, that can be readily integrated with downhole components, is technically challenging.
- An apparatus for estimating at least one parameter includes: a deformable member configured to deform in response to the at least one parameter; a housing surrounding at least a portion of an external surface of the deformable member to define an isolated region around the portion and an isolated surface of the deformable member; and at least one optical fiber sensor disposed on the isolated surface and held in an operable relationship with the isolated surface, the at least one optical fiber sensor configured to generate a signal in response to a deformation of the deformable member.
- a distributed sensor apparatus for estimating at least one parameter includes: a plurality of apparatuses for estimating the at least one parameter, each of the plurality of apparatuses in a distributed relationship with one another, each of the plurality of apparatuses comprising: a deformable member configured to deform in response to the at least one parameter; a housing surrounding at least a portion of an external surface of the deformable member to define an isolated region around the portion and an isolated surface of the deformable member; and at least one optical fiber sensor disposed on the isolated surface and held in an operable relationship with the isolated surface, the at least one optical fiber sensor configured to generate a signal in response to a deformation of the deformable member.
- a method of estimating at least one parameter includes: exposing a deformable member to the at least one parameter, at least a portion of the deformable member being surrounded by a housing to define an isolated region around the portion and an isolated surface of the deformable member; deforming the deformable member; transmitting a measurement signal into at least one optical fiber sensor, the at least one optical fiber sensor disposed on the isolated surface and held in an operable relationship with the isolated surface; receiving a return signal through the optical fiber sensor, the return signal dependent on a deformation of the optical fiber sensor in response to the deforming; and estimating the at least one parameter based on the return signal.
- FIG. 1 is a cross-sectional view of an exemplary non-limiting embodiment of a force and/or pressure transducer
- FIG. 2 is a cross-sectional view of an alternative embodiment of the force and/or pressure transducer of FIG. 1 ;
- FIG. 3 is a cross-sectional view of another alternative embodiment of the force and/or pressure transducer of FIG. 1 ;
- FIG. 4 is a cross-sectional view of an embodiment of a force and/or pressure measurement apparatus
- FIG. 5 is another cross-sectional view of the force and/or pressure measurement apparatus of FIG. 4 ;
- FIG. 6 is a perspective view of an embodiment of a distributed force and/or pressure measurement apparatus
- FIG. 7 is a cross-sectional view of a subterranean well drilling, evaluation, exploration and/or production system.
- FIG. 8 is a flow chart illustrating an exemplary method of estimating a force and/or pressure.
- a Pressure sensing apparatus such as a pressure transducer, and a method for sensing parameters such as temperature, strain, pressure and other forces are described herein.
- the pressure sensing apparatus is configured as a pressure transducer.
- the apparatus includes a deformable member such as a tube that is deformable in response to pressure and/or other forces.
- Such forces include, for example, axial forces and internal pressures exerted on the deformable member.
- a housing isolates at least a portion of the external surface of the deformable member from the forces.
- At least one optical fiber sensor for example an optical fiber including one or more measurement units such as Bragg gratings or Rayleigh scattering fiber regions, is disposed on the elongated member at one or more locations on the isolated surface portion.
- the apparatus is a temperature compensated transducer, which may be incorporated into various tools and components or configured as an independent component.
- the apparatus in one embodiment, is configured to include external pressure or force isolation to facilitate force and/or pressure estimation.
- the apparatus is included in one or more downhole components such as a downhole tool or a drill string, production string or other device configured to be deployed downhole.
- a strain, force and/or pressure transducer 10 includes an elongated member such as a tube 12 and an optical fiber sensor 14 that is disposed on at least a portion of the tube 12 .
- the optical fiber sensor 12 includes an optical fiber having one or more measurement units such as fiber Bragg gratings (FBG) located along the length of the optical fiber sensor 12 .
- Other measurement units may include lengths or regions of the optical fiber sensor 12 utilized for the detection of Rayleigh backscattering signals.
- the elongated member 12 may be any member deformable by a force and/or pressure, and need not take the specific shapes and configurations described herein.
- the transducer 10 is configured to estimate various parameters such as temperature, strain, pressure and other forces exerted at various locations on the transducer 10 .
- parameters include external and internal parameters such as strain, pressure and other forces on the transducer 10 or a device associated with the transducer 10 .
- the transducer is configured to estimate parameters such as external and internal parameters on the same device and/or external and internal parameters co-located on or in the same device.
- the tube 12 is configured to include a pressure and/or force isolated region 16 such as an air gap 16 , which is isolated from the forces on the tube 12 that the transducer 10 is configured to estimate.
- the tube 12 includes a reduced diameter portion 18 , so that the tube 12 includes the reduced diameter portion 18 and a large diameter portion 20 .
- the annular area around the reduced diameter portion 18 extending radially can be isolated from the measured forces.
- the optical fiber sensor 14 is disposed on at least a portion of the exterior surface of the reduced diameter portion, i.e., the isolated surface portion. In one embodiment, the optical fiber sensor 14 is wrapped around and affixed to the reduced diameter portion 18 .
- the shape and configuration of the portion 18 is not limited to those described herein.
- the portion 18 may take any shapes, configuration or size configured to isolate a region from forces and/or pressures exerted on the elongated member 12 .
- a housing or other structure 22 such as a tubular sleeve 22 is disposed about at least a portion of the tube 12 to form the air gap 16 .
- the housing 22 acts to isolate the air gap 16 from external forces such as fluid pressure or forces from other components or materials.
- the reduced diameter portion 18 and the housing 22 both act as pressure boundaries.
- the air gap or other isolated region 16 is at least substantially unaffected by pressures or other forces on the tube 12 , and is also substantially unaffected by pressures or other forces around the exterior of the sleeve or other housing 22 .
- the housing 22 can be connected or attached to the tube 12 by any suitable mechanism, such as a friction fit (e.g., welds) or mechanical sealing methods 24 , and can take any shape or configuration suitable for further defining the isolated region 16 .
- the transducer 10 includes a force, pressure and/or strain insensitive temperature sensor 26 configured to measure the temperature of the tube 12 and/or the reduced diameter portion 18 . This allows for a user or processor to take into account temperature effects on the reduced diameter portion 18 and/or the optical fiber sensor 14 in estimating pressure or other forces on the tube 12 .
- the temperature sensor 26 includes a portion of the optical fiber sensor 12 that is not affected by deformation. For example, the temperature sensor portion is positioned parallel to the major axis of the tube 12 so that expansion or contraction of the tube 12 (due to, e.g., internal pressure) does not affect the temperature sensor portion 26 .
- the optical fiber sensor 14 is positioned on the tube 12 so that one or more portions of the optical fiber sensor 14 are disposed on an exterior surface of the tube 12 that is surrounded by the isolated region 16 , such as on the reduced diameter portion 18 .
- the optical fiber sensor 14 is wrapped around the reduced diameter portion 18 in a spiral or helical manner, forming one or more turns around the reduced diameter portion 18 .
- the sensor 14 is wrapped so that the turns are generally perpendicular to the major axis. Deformation of the tube 12 , particularly the reduced diameter portion 18 , such as expansion or contraction, causes effects such as micro-bends in the optical fiber sensor 14 , which in turn cause a change (e.g., a wavelength shift) in the signal returned by the measurement units.
- a change e.g., a wavelength shift
- This signal change can be used to determine the deformation and estimate force and/or pressure based on the deformation.
- the optical fiber sensor 14 and/or the temperature sensor 26 are in communication with a user, control unit or other processor or storage device via suitable communication mechanisms such as a cable 28 .
- the optical fiber sensor 14 can be connected to the cable 28 , for example, via a splice box 30 .
- the transducer 10 may be configured to be deployed in a borehole for use in subterranean exploration, formation evaluation, drilling and/or hydrocarbon production operations.
- the tube 12 in this example includes connection mechanisms such as threads 32 to allow the transducer 10 to be coupled to other devices or downhole components.
- the transducer 10 is configured as part of a downhole string, such as a production string or drill string.
- the tube 12 is a section of a downhole string such as a pipe section.
- FIG. 2 illustrates another embodiment of the transducer 10 , in which the tube 12 includes a hollow interior 34 coupled to an intake port 36 to allow the transducer 10 to estimate media pressure.
- media refers to any substance capable of moving into at least a portion of the hollow interior 34 or otherwise transferring pressure into the interior 34 . Examples of such media include liquids, gases, flowable solids (e.g., sand) and any combination thereof.
- media is forced into the interior 34 through the intake port 36 , and the radial expansion of the reduced diameter portion 18 is measured via the optical fiber sensor 14 . This information is then transmitted to a user or processor to estimate the fluid pressure.
- This embodiment also illustrates alternative configurations for the cable 28 and the splice box 30 .
- FIG. 3 illustrates another variation in the transducer 10 , in which the transducer 10 is coupled in connection and/or operable communication with other components at both ends of the tube 12 .
- This embodiment shows the ability of the transducer 10 to be coupled as part of a string of components or other transducers 10 .
- a string of transducers can be coupled together to form a distributed force and/or pressure sensing apparatus.
- the string of transducers 10 are connected via a single optical fiber or optical fiber bundle.
- the optical fiber sensor 14 and/or the temperature sensor 26 include a single continuous optical fiber that extends between each end of the transducer 10 .
- an embodiment of a pressure sensing apparatus 40 includes a housing 42 supporting an elongated member such as a cylinder 44 .
- the housing includes conduits 46 to allow for the passage of at least one optical fiber sensor 14 therethrough.
- An isolated portion 48 such as an air gap is formed around a portion of an exterior surface of the elongated member 44 .
- the elongated member 44 is disposed in an opening 50 in the housing 42 , and the isolated portion 48 is formed in the opening 50 between the elongated member 44 and the housing 42 .
- the elongated member 44 is positioned so that its major axis is orthogonal relative to the major axis of the conduits 46 .
- the optical fiber sensor 14 is, in one embodiment, wrapped around the elongated member 44 so that at least one turn is orthogonal to the elongated member's major axis.
- the optical fiber sensor 14 in one embodiment, is at least one continuous optical fiber extending between the ends of the apparatus 40 .
- the elongated member 44 includes a hollow tube 52 , such as a hollow cylinder, having an interior cavity into which media 56 can enter.
- An optional inner member 54 is disposed within the hollow tube 52 and directs the flow of media 56 .
- the media can be inputted directly into an annular space between the inner member 54 and the hollow tube 52 , or may be inputted via a port 58 in communication with passageways 60 through which the media 56 can be directed.
- multiple transducers 10 and/or apparatuses 40 can be operably connected to form a discrete distributed pressure sensing system or apparatus.
- the apparatus 40 is a discrete distributed apparatus including multiple elongated members 44 .
- One or more optical fiber sensors are disposed on each elongated members to provide a pressure sensor at multiple locations.
- the multiple optical fiber sensors are included in a continuous optical fiber that is disposed on and extends between each elongated member 44 .
- an exemplary embodiment of a subterranean well drilling, evaluation, exploration and/or production system 60 includes a borehole string 62 that is shown disposed in a borehole 64 that penetrates at least one earth formation during a subterranean operation.
- the borehole string 52 includes any of various components to facilitate subterranean operations.
- borehole or “wellbore” refers to a single hole that makes up all or part of a drilled well.
- “formations” refer to the various features and materials that may be encountered in a subsurface environment and surround the borehole.
- the system 60 includes a conventional derrick 66 for supporting and/or deploying the borehole string 62 and the various components.
- the borehole string 62 includes one or more pipe sections 68 or coiled tubing that extend downward into the borehole 64 .
- the system 60 is a drilling system and includes a drill bit assembly 70 .
- the system 60 may also include a bottomhole assembly (BHA) 72 .
- BHA bottomhole assembly
- the system 60 and/or the borehole string 62 include any number of downhole tools 74 for various processes including drilling, hydrocarbon production, and formation evaluation (FE) for measuring one or more physical quantities in or around a borehole.
- FE formation evaluation
- the system 60 , the tools 74 , pipe sections 68 , the borehole string 62 and/or the BHA 72 include at least one pressure and/or force sensor 76 , such as the transducer 10 and/or the apparatus 40 .
- the pressure and/or force sensors 76 are configured to measure various forces on system components, in the borehole 62 and/or in the surrounding formation. Exemplary forces include pressure from drilling, production and/or borehole fluids, pressure from formation materials, and axial force on components of the borehole string 62 , tools 72 or other downhole components of the system 60 .
- the tools 72 and/or pressure sensors 76 are equipped with transmission equipment to communicate ultimately to a surface processing unit 78 .
- Such transmission equipment may take any desired form, and different transmission media and connections may be used.
- the optical fiber sensor 14 is coupled to other optical fibers to transmit signals related to pressure and/or force to the surface processing unit 78 .
- the surface processing unit 78 , the pressure sensors 76 , and/or other components of the system 60 include devices as necessary to provide for storing and/or processing data collected from the pressure sensors 76 and other components of the system 60 .
- Exemplary devices include, without limitation, at least one processor, storage, memory, input devices, output devices and the like.
- FIG. 8 illustrates a method 80 of estimating a force and/or pressure.
- the method 80 includes one or more stages 81 - 84 .
- the method 80 is described in conjunction with pressure and/or force sensing apparatuses such as the transducer 10 or the apparatus 40 , the method 80 is not limited to use with these embodiments.
- the method 80 includes the execution of all of stages 81 - 84 in the order described. However, certain stages may be omitted, stages may be added, or the order of the stages changed.
- a pressure sensing apparatus such as the transducer 10 or the apparatus 40 is exposed to a force and/or pressure.
- the pressure sensing apparatus is a pipe section or other component deployed in a downhole environment.
- a parameter such as force and/or pressure is applied to the elongated member of the apparatus to deform the elongated member.
- forces include axial forces on the elongated member and media pressure on an interior of the elongated member.
- a force may include an axial force (i.e., a force generally parallel to the major axis of the elongated member) exerted by a borehole string and/or a pressure exerted by borehole fluids inputted into the elongated member.
- the elongated member deforms in response to the force and/or pressure, such as by radially expanding or contracting, resulting in an increase or decrease in diameter.
- a measurement signal such as light having one or more selected wavelengths is generated and transmitted into the optical fiber sensor.
- the optical fiber sensor and/or measurement units reflect a portion of the measurement signal as a return signal. Deformation of the optical fiber sensor, such as microbending, due to deformation of the elongated member, causes the return signal to change (e.g., shift wavelength).
- the return signal is received by an appropriate user or processor.
- the return signal change is analyzed to estimate at least one parameter on the elongated member.
- the return signal change is used to determine the strain of the elongated member, which is in turn used to estimate the corresponding force and/or pressure.
- the temperature is also determined from signals received from the pressure insensitive temperature sensor in order to properly account for the affect of temperature on the return signals from the optical fiber sensor.
- the optical fiber sensor can be wrapped around or otherwise disposed on a pressure and/or force isolated portion of a member, thereby increasing the sensitivity of the apparatus by increasing the sensitivity of the optical fiber sensor to pressure induced deformations of the member, as well as provide the pressure delta required to allow for deformation of the member.
- the configurations described above allow for multiple pressure sensing regions to be placed on a single fiber, allowing for the creation of a distributed sensing apparatus having multiple discrete sensors or a continuous string for, e.g., pressure profiling.
- the apparatus can be easily incorporated into existing structures (e.g. a modified section of production tubing) or be included as a separate transducer.
- various analyses and/or analytical components may be used, including digital and/or analog systems.
- the apparatus may have components such as a processor, storage media, memory, input, output, communications link (wired, wireless, pulsed mud, optical or other), user interfaces, software programs, signal processors (digital or analog) and other such components (such as resistors, capacitors, inductors and others) to provide for operation and analyses of the apparatus and methods disclosed herein in any of several manners well-appreciated in the art.
- teachings may be, but need not be, implemented in conjunction with a set of computer executable instructions stored on a computer readable medium, including memory (ROMs, RAMs), optical (CD-ROMs), or magnetic (disks, hard drives), or any other type that when executed causes a computer to implement the method of the present invention.
- ROMs, RAMs random access memory
- CD-ROMs compact disc-read only memory
- magnetic (disks, hard drives) any other type that when executed causes a computer to implement the method of the present invention.
- These instructions may provide for equipment operation, control, data collection and analysis and other functions deemed relevant by a system designer, owner, user or other such personnel, in addition to the functions described in this disclosure.
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Abstract
Description
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Priority Applications (2)
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US12/956,777 US9476294B2 (en) | 2010-01-29 | 2010-11-30 | Device and method for discrete distributed optical fiber pressure sensing |
SA111320138A SA111320138B1 (en) | 2010-01-29 | 2011-01-26 | Device and Method for Discrete Distributed Optical Fiber Pressure Sensing |
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US29971210P | 2010-01-29 | 2010-01-29 | |
US12/956,777 US9476294B2 (en) | 2010-01-29 | 2010-11-30 | Device and method for discrete distributed optical fiber pressure sensing |
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US20110191031A1 US20110191031A1 (en) | 2011-08-04 |
US9476294B2 true US9476294B2 (en) | 2016-10-25 |
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AU (1) | AU2011209599B2 (en) |
BR (1) | BR112012018546B1 (en) |
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GB (1) | GB2489889B (en) |
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US20180156641A1 (en) * | 2016-03-01 | 2018-06-07 | Cmiws Co., Ltd. | Optical fiber sensor |
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US11401002B2 (en) | 2018-05-11 | 2022-08-02 | Campagnolo S.R.L. | Bicycle crankarm having a stress/strain detector for a torque meter or a power meter, and methods for manufacturing and using the crankarm |
US11547004B2 (en) | 2018-05-11 | 2023-01-03 | Campagnolo S.R.L. | Bicycle component made of composite material and related manufacturing process |
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US20170205304A1 (en) * | 2014-10-03 | 2017-07-20 | Tlv Co., Ltd. | Sensor device |
US10012559B2 (en) * | 2014-10-03 | 2018-07-03 | Tlv Co., Ltd. | Sensor device having body, pressure sensor, insert with helically shaped groove and temperature sensor |
US20180156641A1 (en) * | 2016-03-01 | 2018-06-07 | Cmiws Co., Ltd. | Optical fiber sensor |
US10663324B2 (en) * | 2016-03-01 | 2020-05-26 | Cmiws Co., Ltd. | Optical fiber sensor |
US20190346318A1 (en) * | 2018-05-11 | 2019-11-14 | Campagnolo S.R.L. | Bicycle component provided with a temperature-compensated stress/strain sensor |
US11214331B2 (en) * | 2018-05-11 | 2022-01-04 | Campagnolo S.R.L. | Bicycle component provided with a temperature-compensated stress/strain sensor |
US11377169B2 (en) | 2018-05-11 | 2022-07-05 | Campagnolo S.R.L. | Bicycle crankarm and related crankset |
US11401002B2 (en) | 2018-05-11 | 2022-08-02 | Campagnolo S.R.L. | Bicycle crankarm having a stress/strain detector for a torque meter or a power meter, and methods for manufacturing and using the crankarm |
US11547004B2 (en) | 2018-05-11 | 2023-01-03 | Campagnolo S.R.L. | Bicycle component made of composite material and related manufacturing process |
US11577801B2 (en) | 2018-05-11 | 2023-02-14 | Campagnolo S.R.L. | Bicycle component provided with a temperature-compensated stress/strain sensor |
US11597469B2 (en) | 2018-05-11 | 2023-03-07 | Campagnolo S.R.L. | Bicycle crankarm provided with electric/electronic system |
Also Published As
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AU2011209599B2 (en) | 2015-01-29 |
WO2011094331A2 (en) | 2011-08-04 |
MY179995A (en) | 2020-11-19 |
BR112012018546A2 (en) | 2016-05-03 |
NO344068B1 (en) | 2019-08-26 |
NO20120819A1 (en) | 2012-07-30 |
US20110191031A1 (en) | 2011-08-04 |
CA2788335C (en) | 2015-11-24 |
GB2489889A (en) | 2012-10-10 |
GB201213744D0 (en) | 2012-09-12 |
SA111320138B1 (en) | 2015-01-21 |
AU2011209599A1 (en) | 2012-08-09 |
GB2489889B (en) | 2017-05-03 |
WO2011094331A4 (en) | 2011-12-29 |
BR112012018546B1 (en) | 2020-09-24 |
CA2788335A1 (en) | 2011-08-04 |
WO2011094331A3 (en) | 2011-11-10 |
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